JP2023088158A - Distributed energy resource management device, distributed energy resource management system, and distributed energy resource management program - Google Patents

Abstract

To obtain a DER management device that can provide a VPP aggregator with a range of effective power control quantities for each DER while meeting grid voltage and current constraints for grid supply and demand coordination.SOLUTION: A DER management device 2 includes an optimum tidal current calculation unit 24, a control command value calculation unit, and a communication unit 21. The optimum tidal current calculation unit 24 calculates the maximum values of the charge and discharge quantities that can be output in the range of a controllable first amount of power of a first DER in a period to be controlled, provided that the constraints on the voltage and current of a distribution system are observed from voltage and current distributions of the distribution system based on supply and demand forecasts, and determines an effective power control range defined by the maximum values of the charge and discharge quantities. The control command value calculation unit generates first control command information in which each of the plurality of first DERs is associated with the effective power control range. The communication unit 21 transmits the first control command information to a VPP aggregator that determines the effective power amount to be commanded to the plurality of first DERs.SELECTED DRAWING: Figure 3

Description

The present disclosure relates to a distributed energy resource management device, a distributed energy resource management system, and a distributed energy resource management program that manage charging/discharging power amounts in accordance with supply and demand adjustment of distributed energy resources such as storage batteries.

At present, distributed energy resources (DER) including photovoltaic power generation equipment, storage batteries, electric vehicles, etc. as energy equipment are widespread. Technology for supply and demand control using DER is being studied for the case where DER is widely spread. There is a virtual power plant (VPP) that is regarded as a substation.

On the other hand, when a large amount of DER is interconnected, a distribution system may experience a current violation, in which the current is out of the specified range, or a voltage violation, in which the voltage is out of the specified range. In order to prepare for current or voltage violations, additional equipment investments such as voltage regulators are required. Therefore, there is a DER management device as a technique for appropriately controlling DER in order to suppress capital investment when DER is widely used.

In addition, in Patent Document 1, when the output of DER fluctuates greatly, the voltage fluctuation range in the power system is predicted so that the voltage does not violate the voltage of the power system, and voltage control of the power system is performed in advance. Techniques for doing so are disclosed.

JP 2017-108489 A

However, in the technique described in Patent Document 1, the control amount for voltage control of the electric power system is determined only for the purpose of eliminating the voltage violation of the electric power system, and it is not necessary to match the supply and demand of electric power. is not considered. In addition, when the VPP aggregator adjusts power supply and demand, the VPP aggregator described above does not have system information indicating the distribution of voltage and current in the distribution system, so it cannot adjust supply and demand in consideration of the system status. As a result, the VPP aggregator's control of the active energy for power supply and demand adjustment may cause voltage and current violations in the distribution system. For this reason, there has been a demand for a technology that enables the VPP aggregator to control the active power amount of each DER while considering voltage and current constraints for grid supply and demand adjustment.

The present disclosure has been made in view of the above, and provides a VPP aggregator with a range of active power control amounts for each DER while satisfying system voltage and current constraints for system supply and demand adjustment. It is an object of the present invention to obtain a distributed energy resource management device capable of

To solve the above-described problems and achieve the object, the present disclosure calculates an output in a distributed energy resource including a plurality of first distributed energy resources connected to a distribution system and whose output active power is controlled. It is a distributed energy resource management device. A distributed energy resource management device includes an optimum power flow calculation unit, a control command value calculation unit, and a communication unit. The optimum power flow calculation unit calculates the controllable first power amount of the first distributed energy resource in the control target period while observing the voltage and current constraints of the distribution system from the voltage and current distribution of the distribution system based on the supply and demand forecast. The maximum values of the charge amount and the discharge amount that can be output within the range are calculated, and the active power control range defined by the maximum values of the charge amount and the discharge amount is determined. The control command value calculator generates first control command information in which each of the plurality of first distributed energy resources and the active power control range are associated with each other. The communication unit transmits first control command information to a virtual substation aggregator that determines active power amounts to be commanded to a plurality of first distributed energy resources. The active power control range is the control range of active power output from the first distributed energy resource.

Advantageous Effects of Invention According to the present disclosure, it is possible to provide a VPP aggregator with a range of active power control amounts for each DER while satisfying system voltage and current constraints for grid supply and demand adjustment.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a diagram schematically showing an example of a configuration of a distributed energy resource management system and a power system to be controlled according to Embodiment 1; FIG. 1 is a diagram schematically showing an example of the configuration of DER provided in the DER management system according to Embodiment 1; FIG. 1 is a diagram schematically showing an example of the configuration of a DER management device provided in the DER management system according to Embodiment 1; FIG. 2 is a diagram schematically showing an example of configuration of a VPP aggregator provided in the DER management system according to Embodiment 1; 1 is a diagram schematically showing an example of the configuration of a power distribution automation system provided in the DER management system according to Embodiment 1; FIG. Flowchart showing an example of the procedure of the DER management method according to the first embodiment Flowchart showing an example of the procedure of the DER management method according to the first embodiment A diagram schematically showing an example of the configuration of a distribution system A diagram showing an example of voltage distribution in the distribution system shown in FIG. A diagram showing an example of charge/discharge amounts in each DER of the distribution system shown in FIG. A diagram showing an example of voltage control in the second DER Flowchart showing an example of the procedure of command value calculation processing of the VPP aggregator in the DER management system according to the first embodiment Flowchart showing an example of the procedure of setting value setting processing of the power distribution automation system in the DER management system according to the first embodiment 1 is a diagram showing an example of the configuration of a computer system that realizes a DER management device, a VPP aggregator, and a power distribution automation system used in the DER management system according to the first embodiment; FIG. Flowchart showing an example of the procedure of the DER management method according to the second embodiment A diagram showing an example of voltage distribution in the distribution system shown in FIG. A diagram schematically showing an example of a configuration of a DER management system according to a third embodiment A diagram schematically showing an example of a configuration of a DER management device according to a third embodiment Flowchart showing an example of the procedure of the DER management method according to the third embodiment Flowchart showing an example of the procedure of the DER management method according to the fourth embodiment A diagram schematically showing an example of a configuration of a DER management device according to a fifth embodiment FIG. 12 is a diagram schematically showing an example of the configuration of a power distribution automation system according to Embodiment 5; A diagram schematically showing an example of the configuration of the DER management system according to the fifth embodiment FIG. 12 is a diagram schematically showing another example of the configuration of the DER management system according to the fifth embodiment; FIG. 12 is a diagram schematically showing another example of the configuration of the DER management device according to the fifth embodiment;

A distributed energy resource management device, a distributed energy resource management system, and a distributed energy resource management program according to embodiments of the present disclosure will be described below in detail with reference to the drawings.

Embodiment 1.
FIG. 1 is a diagram schematically showing an example of the configuration of a distributed energy resource management system and a power system to be controlled according to Embodiment 1. FIG. In Embodiment 1, a distributed energy resource management system comprising a distributed energy resource management device 2, a virtual substation aggregator 3, a distribution automation system 4, a load 5, and a first distributed energy resource 6a The system 1 controls the active power control amount of the first distributed energy resource 6a so that the demand and supply of the power system match within the range that satisfies the power system constraints in the power system to be controlled. Power system constraints include constraints that the voltage and current in the power system to be controlled must satisfy. In the following, the distributed energy resource management system 1 is called DER management system 1, the distributed energy resource management device 2 is called DER management device 2, and the distributed energy resource is called DER. The virtual substation aggregator 3 is also called a VPP aggregator 3 .

Further, in Embodiment 1, the DER management system 1 further including the second DER 6b controls the effectiveness of the first DER 6a so that the demand and supply of the power system match within the range that satisfies the power system constraints in the power system to be controlled. It controls the amount of power control and determines the amount of reactive power control and the set value of the second DER 6b.

In the following, a case where the power system to be controlled is the distribution system 100 will be taken as an example. In the distribution system 100 of the DER management system 1 , a distribution line 103 is connected to a distribution transformer 101 via a bus line 102 . The distribution line 103 is, for example, a high voltage distribution line such as 6600V. Although not shown, the distribution line 103 may be connected to a pole transformer or the like. A pole transformer is a transformer that converts high-voltage power such as 6600V into low-voltage power such as 100V or 200V and outputs the power to a low-voltage distribution line. Moreover, although not shown, the distribution line 103 may be provided with a voltage regulator. An example of a voltage regulator is an SVR (Step Voltage Regulator). The SVR is a voltage control device that controls the voltage in the distribution line 103 so that the voltage in the distribution line 103 falls within the proper range defined by the power system constraints.

The distribution line 103 is connected to the load 5 and the first DER 6a or the second DER 6b. The load 5 is a device that consumes power owned by the consumer 7 . The consumer 7 receives power supply from the distribution line 103 . The first DER 6a and the second DER 6b are equipment that the customer 7 has and can be charged and discharged or can generate power. Equipment that can be charged and discharged may include equipment that can only be charged. In the following, the amount of charge indicates the amount of charge stored in the case of equipment in which the first DER 6a and the second DER 6b can be charged and discharged. When equipment is included, it also includes the amount of power generation restraint in equipment capable of generating power. In addition, the amount of discharge indicates the amount of charge released in the case of equipment in which the first DER 6a and the second DER 6b can be charged and discharged. If included, include the amount of power generated by facilities capable of generating power. However, when the first DER 6a or the second DER 6b indicates equipment capable of generating power, that is, when charging/discharging equipment is not included, the power generation amount is expressed as power generation amount.

The first DER 6a is a DER in which power supply and demand control is performed by active power. The second DER 6b is a DER that has a voltage control function and voltage control is performed by reactive power. The first DER 6a is also a DER without a voltage control function. In the following description, the first DER 6a and the second DER 6b are referred to as DER 6 when the first DER 6a and the second DER 6b are not distinguished from each other.

Although the example of FIG. 1 shows the case where all the consumers 7 have the first DER 6a or the second DER 6b, not all the consumers 7 need to have the DER 6. The first DER 6 a transmits to the VPP aggregator 3 via the communication network 71 the first controllable power amount, which is the controllable power amount for each predetermined period to be controlled. The first DER 6 a controls the charge/discharge amount or the power generation amount according to the command from the VPP aggregator 3 . In the following, the defined period to be controlled is referred to as the controlled period. The second DER 6 b transmits the second controllable power amount, which is the controllable power amount for each control target period, to the power distribution automation system 4 via the communication network 72 . The second DER 6b controls the amount of reactive power according to commands from the distribution automation system 4. FIG. The first controllable amount of power corresponds to the first amount of power, and the second controllable amount of power corresponds to the second amount of power. The communication networks 71 and 72 may be the Internet or dedicated lines. Also, the communication networks 71 and 72 may be wired networks, wireless networks, or may include both.

The DER management device 2 is a device that calculates the output control range of the DERs 6 including the plurality of first DERs 6 a connected to the distribution system 100 . The DER management device 2 uses information from the VPP aggregator 3 connected to the communication network 73 to satisfy the power system constraints of the distribution system 100, and then charges and discharges the first DER 6a of each distribution line 103 of the distribution system 100. Determine the active power control range, which is the range of possible control amounts. Further, when the second DER 6b is included in the DER management system 1, the DER management device 2 uses information from the distribution automation system 4 connected to the communication network 73 to satisfy the power system constraints of the distribution system 100. Above, the reactive power control amount of the second DER 6b of each distribution line 103 of the distribution system 100 and the setting value that defines the range in which the control of the reactive power amount is executed are determined. The DER management device 2 transmits the active power control range to the VPP aggregator 3 via the communication network 73 , and transmits the reactive power control amount and the set value to the distribution automation system 4 via the communication network 73 .

The VPP aggregator 3 is a device that manages the amount of charge or discharge of the DER 6 owned by the customer 7 . The VPP aggregator 3 is a device provided by a business that manages the amount of charge or discharge of the DER 6 of the consumer 7 . In Embodiment 1, the VPP aggregator 3 is a device that determines active power amounts to be commanded to the plurality of first DERs 6a for supply and demand adjustment. The VPP aggregator 3 collects the first controllable power amount from the first DER 6 a and transmits the first controllable power amount to the DER management device 2 via the communication network 73 . In addition, when the VPP aggregator 3 receives the active power control range from the DER management device 2, the active power control amount for each first DER 6a that minimizes the operation cost for adjusting power supply and demand within the active power control range, and output plan information that defines the timing of outputting the active power control amount for each first DER 6a. The VPP aggregator 3 transmits the output plan information to each first DER 6a via the communication network 71 as a first control command value. The output plan information is, for example, information defining at what timing each first DER 6a outputs what amount of active power control amount within the control target period. Note that FIG. 1 shows a case where the VPP aggregator 3 determines the control amount for supply and demand control for the DER 6 connected to the distribution system 100, but other than the distribution system 100 in its own system (not shown) The charge amount or discharge amount is also managed for the DER 6 connected to the distribution system.

The distribution automation system 4 collects the second controllable power amount from the second DER 6 b and transmits the second controllable power amount to the DER management device 2 via the communication network 73 . In addition, when the distribution automation system 4 receives the reactive power control amount and the setting value for each second DER 6b from the DER management device 2, the power distribution automation system 4 uses the reactive power control amount and the setting value as the second control command value to each Send to the second DER 6b.

Next, detailed configurations of the DER 6, the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 will be described. FIG. 2 is a diagram schematically showing an example of the configuration of DER provided in the DER management system according to the first embodiment. Since the basic configuration is the same for the first DER 6a and the second DER 6b, they will be collectively described in FIG. DER 6 comprises a distributed energy device 61 and a power controller 62 .

The distributed energy device 61 is arranged between an energy facility (not shown) that performs charging/discharging or power generation, and the power distribution system 100 and the energy facility, and is a PCS (Power Conditioning Subsystem: power conditioner) that controls power in the energy facility. , and an energy control unit (not shown) such as an inverter. Examples of energy equipment include charging/discharging equipment, such as electric vehicles and storage batteries, and power generation equipment, such as solar power generation equipment. When the energy equipment is an electric vehicle, the energy control unit is a charging/discharging device that controls charging/discharging of a storage battery mounted on the electric vehicle. When the energy equipment is a storage battery, the energy control unit is a PCS that controls charging and discharging of the storage battery. When the energy facility is a photovoltaic power generation facility, the energy control unit is a PCS that converts the power generated by the photovoltaic power generation facility into AC power and controls the output power of the photovoltaic power generation facility.

When the DER 6 is the first DER 6a, the distributed energy device 61 is a device whose output active power is controlled. Also, when the DER 6 is the first DER 6a, the distributed energy device 61 does not have a voltage control function. When the DER 6 is the second DER 6b, the distributed energy device 61 is a device that has a voltage control function and whose output reactive power is controlled. When the connection point voltage with the distribution system 100 deviates from the dead band determined by the specified setting value, the voltage control function outputs reactive power so that the connection point voltage falls within the dead band, and the voltage of the second DER 6b is a function that controls

The power control device 62 acquires the controllable power amount for each control target period of the DER 6 and transmits it to the VPP aggregator 3 or the power distribution automation system 4 . The controllable power amount includes a first controllable power amount for the first DER 6a and a second controllable power amount for the second DER 6b. Also, the power control device 62 controls the power of the distributed energy device 61 according to the first control command value or the second control command value acquired from the VPP aggregator 3 or the power distribution automation system 4 . An example of the control target period is a period during which the DER management device 2 and the VPP aggregator 3 predict power supply and demand, such as 30 minutes and 1 hour. The power control device 62 includes a communication section 621 , a controllable power calculation section 622 , a storage section 623 and a control section 624 .

The communication unit 621 communicates with the VPP aggregator 3 or the power distribution automation system 4 via the communication networks 71 and 72 . In one example, the communication unit 621 transmits the controllable power amount of the distributed energy device 61 calculated by the controllable power calculation unit 622 to the VPP aggregator 3 in the case of the first DER 6a, and to the power distribution in the case of the second DER 6b. Send to automation system 4 . Also, in the case of the first DER 6a, the communication unit 621 receives the first control command value for the first DER 6a received from the VPP aggregator 3 and stores it in the storage unit 623 . In the case of the second DER 6b, the communication unit 621 receives the second control command value for the second DER 6b received from the power distribution automation system 4 and stores it in the storage unit 623 .

The controllable power calculation unit 622 calculates a controllable power amount, which is the power amount that can be controlled by the distributed energy device 61 in the control target period, and outputs the controllable power amount to the communication unit 621 . The control target period is, as described above, 30 minutes, 1 hour, or the like. When the distributed energy device 61 has a solar power generation facility as an energy facility, the controllable power amount is the amount that can suppress the power generation capacity of the solar power generation facility at the time of calculation during the control target period. When the distributed energy device 61 has a storage battery as energy equipment, the amount of energy (state of charge: SoC) stored in the storage battery that can be continuously discharged or charged during the control target period can be maintained. is the controllable power amount. Since the SoC of the storage battery changes from moment to moment, the amount that can be discharged or the amount that can be charged also changes at the time of calculation. The case where distributed energy system 61 has an electric vehicle as energy equipment is the same as the case where distributed energy system 61 has a storage battery as energy equipment.

The storage unit 623 stores the first control command value received from the VPP aggregator 3 via the communication unit 621 in the case of the first DER 6a, and the power distribution automation system 4 via the communication unit 621 in the case of the second DER 6b. stores the second control command value received from. When the DER6 is the first DER6a, the first control command value is the output plan information, and when the DER6 is the second DER6b, the second control command value is the reactive power control amount and the set value. Hereinafter, when the first control command value and the second control command value are not distinguished, the first control command value and the second control command value are simply referred to as the control command value.

Control unit 624 controls distributed energy device 61 using the control command value. In the case of the first DER 6a, the control unit 624 refers to the output plan information, which is the first control command value stored in the storage unit 623, and outputs the specified amount at the time specified by the output plan information. A command is output to the distributed energy device 61 to control the distributed energy device 61 as follows. The control unit 624 sets the set value stored in the storage unit 623 in the distributed energy device 61 in the case of the second DER 6b.

FIG. 3 is a diagram schematically showing an example of a configuration of a DER management device provided in the DER management system according to Embodiment 1; The DER management device 2 includes a communication unit 21 , a storage unit 22 , a prediction unit 23 , an optimum power flow calculation unit 24 and a DER control command value calculation unit 25 .

The communication unit 21 communicates with the VPP aggregator 3 and the power distribution automation system 4 via the communication network 73 . In one example, the communication unit 21 receives the first controllable power amount of the first DER 6 a from the VPP aggregator 3 and stores it in the storage unit 22 . The communication unit 21 receives the second controllable power amount of the second DER 6 b from the distribution automation system 4 and stores it in the storage unit 22 . Further, the communication unit 21 transmits first control command information for the first DER 6a calculated by the DER control command value calculation unit 25 to the VPP aggregator 3, and transmits second control command information for the second DER 6b to the power distribution automation system 4. .

The storage unit 22 stores the first controllable power amount of the first DER 6 a received from the VPP aggregator 3 and the second controllable power amount of the second DER 6 b received from the distribution automation system 4 . The storage unit 22 also stores actual load power generation information including the actual value of the load demand and the actual value of the power generation profile in the distribution system 100 . The actual value of load demand is past data of the amount of electric power requested by the load 5 connected to the power distribution system 100 in each time slot of the day. The actual value of the power generation profile is past data of the amount of electric power generated by the DER connected to the power distribution system 100 and capable of generating power in each time slot of the day. The actual value of the load demand and the actual value of the power generation profile are, in one example, data collected from measuring devices (not shown) installed in the load 5 and the DER 6, respectively. For example, the actual load power generation information is desirably information that associates the actual value of the load demand and the actual value of the power generation profile with at least one of the type of day and weather conditions. The type of day is information indicating the type of day such as weekdays and holidays, and the weather condition is information such as weather and temperature.

The prediction unit 23 predicts the load demand of the load 5 connected to the distribution system 100 and the power generation amount of the DER that can be generated in the control target period based on the load power generation record information, and predicts the control target period based on the prediction result. to estimate the distribution of voltage and current in the distribution line 103 of the distribution system 100 at . The control target period is a period during which the DER management device 2 predicts supply and demand, and is 30 minutes, 1 hour, or the like. Specifically, the prediction unit 23 acquires the actual value of the load demand for the period corresponding to the control target period from the load power generation performance information, performs statistical processing, and predicts the load demand for the control target period. The prediction unit 23 also acquires the actual value of the power generation profile for the period corresponding to the control target period from the load power generation performance information, and performs statistical processing or the like to predict the power generation amount for the control target period. Hereinafter, the predicted load demand and power generation amount in the control target period are referred to as a load demand prediction value and a power generation prediction value, respectively. At this time, if the actual load power generation information includes information on at least one of the type of day and weather conditions, the actual value of the load demand and the power generation on a day with conditions similar to the day on which the forecast is made using this information. The actual value of the profile can be used to predict the load demand forecast value and the power generation forecast value. As a result, it is possible to improve the prediction accuracy of the load demand and power generation amount in the control target period.

In addition, the prediction unit 23 uses the load demand prediction value and the power generation amount prediction value in the control target period to determine the voltage at the connection point between each distribution line 103 and the DER 6 of the distribution system 100 and the line between the connection points. Calculate the current that flows. As a result, the voltage distribution, which is the distribution of voltage, and the current distribution, which is the distribution of current, in the distribution line 103 can be estimated. In the following, the voltage distribution and the current distribution together will be referred to as the voltage-current distribution.

The optimum power flow calculation unit 24 uses the controllable power amount of DER 6 obtained from the VPP aggregator 3 and the distribution automation system 4 as variables, and calculates the estimated voltage and current distribution so that the power system constraints of the distribution system 100 are observed. Solve the optimization problem to maximize the amount of discharge and charge of the first DER 6a and minimize the amount of reactive power control of the second DER 6b.

Specifically, the optimum power flow calculation unit 24 uses the first controllable power amount and the second controllable power amount as variables, and under the constraint condition that the power system constraint is observed for the estimated voltage current distribution, , solves a first optimization problem that maximizes the amount of discharge in the first DER 6a and minimizes the amount of reactive power in the second DER 6b that has the effect of voltage drop. In addition, the optimum power flow calculation unit 24 uses the first controllable power amount and the second controllable power amount as variables, and maximizes the charging amount of the first DER 6a with respect to the estimated voltage-current distribution, and has the effect of increasing the voltage. Solve a second optimization problem that minimizes the reactive energy of the second DER 6b. Here, if the DER 6 is a power-generating DER, the calculation is performed assuming that the power generation capacity is reduced from the power generation capacity at the time of calculation, that is, the power generation capacity is suppressed as charging.

By solving the first optimization problem, the maximized discharge amount of each first DER 6a and the minimized first reactive energy amount of each second DER 6b with voltage drop effect are obtained. By using the maximized discharge amount of each first DER 6a in the distribution line 103, the voltage-current distribution when the discharge amount is maximized is obtained. By solving the second optimization problem, the maximized charge amount of each first DER 6a and the minimized second reactive energy amount of each second DER 6b that has the effect of raising the voltage are obtained. By using the maximized charge amount of each first DER 6a in the distribution line 103, the voltage-current distribution when the charge amount is maximized is obtained.

For each first DER 6a, the optimum power flow calculator 24 determines an active power control range, which is a range of active power with the maximum discharge amount as the lower limit and the maximum charge amount as the upper limit. The optimum power flow calculation unit 24 uses the first reactive power amount and the second reactive power amount for each second DER 6b as reactive power control amounts.

In one example, in a system state in which the amount of power generated in the DER that can generate power in the control target period is large, voltage violations and current violations due to voltage rises are likely to occur in the distribution line 103 . In such a situation, when the DER 6 discharges, the voltage further rises, and voltage violations and current violations tend to occur due to the voltage rise. Therefore, in the distribution line 103 of FIG. 1, the discharge amount that maximizes the discharge amount of the first DER 6a is set so that the voltage and current of the interconnection point connected to the consumer 7 comply with the power system restrictions. For the second DER 6b, the first reactive energy, which is the minimized reactive energy, is obtained. As a result, a voltage-current distribution is obtained when the amount of discharge that satisfies the constraints of the power system is maximized while adjusting the power supply and demand in the distribution line 103 .

In addition, in a system state in which the amount of power generated by the DER that can generate power in the control target period is small, voltage violations and current violations due to voltage drops are likely to occur in the distribution line 103 . In such a situation, when the DER 6 is charged, the voltage drops further, and voltage violations and current violations due to the voltage drop are likely to occur. In the distribution line 103 of FIG. 1, the charging amount of the first DER 6a is maximized so that the voltage and current of the interconnection point connected to the consumer 7 comply with the power system restrictions, For the second DER 6b, a second reactive power amount, which is the minimized reactive power amount, is obtained. As a result, a voltage-current distribution is obtained when the amount of charge that satisfies the power system constraint is maximized while adjusting the power supply and demand in the distribution line 103 .

In addition, when the second DER 6b does not exist in the distribution system 100, the optimum power flow calculation unit 24 uses the first controllable power amount acquired from the VPP aggregator 3 as a variable, and the estimated voltage and current distribution is subjected to the power system constraint Solve the optimization problem to maximize the discharge and charge of the first DER 6a under the constraint that . Thereby, the maximized discharge amount and the maximized charge amount of each first DER 6a are obtained.

As described above, when the second DER 6b does not exist in the distribution system 100, the optimum power flow calculation unit 24 calculates the voltage and current distribution of the distribution system 100 based on the supply and demand forecast, and the power system constraints on the voltage and current of the distribution system 100. is observed, and the maximum value of the charge amount and the discharge amount that can be output within the range of the first controllable power amount that can be controlled by the first DER 6a in the control target period is calculated, and the effective amount determined by the maximum value of the discharge amount and the charge amount Determine the power control range. In addition, when the second DER 6b exists in the distribution system 100, the optimum power flow calculation unit 24 determines that the power system constraints of the distribution system 100 are observed from the voltage current distribution in addition to the active power control range, and A reactive power control amount, which is the minimum value of the reactive power amount that can be output within the range of the second controllable power amount that can be controlled by the second DER 6b, is calculated.

When maximizing the amount of charge and the amount of discharge, priority or weight may be set for the first DER 6a. In this case, priorities or weights are set in advance for the first DER 6a in the DER management device 2, and the optimum power flow calculator 24 solves the optimization problem according to the set priorities or weights. As a result, it is possible to maximize the amount of charge and the amount of discharge of the first DER 6a to be prioritized under the constraint condition that the power system constraint is observed. Similarly, the priority or weight may be set for the second DER 6b.

The DER control command value calculator 25 generates control command information for each DER 6 from the active power control range of the first DER 6a calculated by the optimum power flow calculator 24 and the reactive power control amount of the second DER 6b. Specifically, for the first DERs 6a, the DER control command value calculator 25 generates first control command information in which each first DER 6a and the active power control range calculated by the optimum power flow calculator 24 are associated with each other. For the second DER 6b, the DER control command value calculation unit 25 uses the reactive power control amount, the voltage-current distribution when the discharge amount is maximized, and the voltage-current distribution when the charge amount is maximized to obtain the second 2DER 6b calculates a set value to be used for voltage control by reactive power. The DER control command value calculator 25 generates second control command information in which each second DER 6b is associated with the reactive power control amount and the set value. Calculation of the set value will be described later. The first control command information for the first DER 6a is transmitted to the VPP aggregator 3 via the communication unit 21, and the second control command information for the second DER 6b is transmitted to the distribution automation system 4 via the communication unit 21. sent. The DER control command value calculator 25 corresponds to the control command value calculator.

FIG. 4 is a diagram schematically showing an example of the configuration of a VPP aggregator provided in the DER management system according to Embodiment 1. FIG. The VPP aggregator 3 includes a communication unit 31 , a DER controllable amount collection unit 32 , a storage unit 33 , a demand prediction unit 34 , a required adjustment force estimation unit 35 and a DER control command value determination unit 36 .

The communication unit 31 communicates with the first DER 6 a and the DER management device 2 via communication networks 71 and 73 . In one example, the communication unit 31 transmits the first controllable power amount of each first DER 6 a collected by the DER controllable amount collecting unit 32 to the DER management device 2 . Further, the communication unit 31 receives the first control command information about each first DER 6a received from the DER management device 2, and uses the output plan information determined by the DER control command value determination unit 36 as the first control command value. Send to 1DER 6a.

The DER controllable amount collecting unit 32 collects the first controllable power amount from the first DER 6a for each control target period. The DER controllable amount collecting unit 32 stores the collected first controllable power amount in the storage unit 33 .

The storage unit 33 stores the controllable power amount information collected by the DER controllable amount collecting unit 32 . The storage unit 33 also stores actual supply and demand information used for supply and demand prediction of electric power in the distribution system 100 . The actual supply and demand information is, for example, the actual value of power demand for the load 5 in the past, the actual output value of renewable energy, which is the amount of power output by the DER that can be generated, and the amount of power flowing through the interconnection line with other systems. Power flow actual values for other grids, actual power output values for generators within the own system, which are actual values for the amount of power output by thermal power generators, etc. within the own system, and power generation status, including day type, weather conditions, and time of day It is information in which information and are associated with each other. The type of day is information indicating the type of day, such as weekdays and holidays. Weather conditions are information such as weather and temperature. is information indicating Here, the amount of power output by the DER that can generate power is referred to as renewable energy output in order to distinguish it from the amount of power output by a thermal power generator or the like.

The demand prediction unit 34 predicts and stores the load demand, renewable energy output, power flow connected to other grids, and power generator output such as a thermal power generator in the own system during the control target period in the own system of the control target. Store in section 33 . In one example, the demand forecasting unit 34 acquires past actual supply and demand information for the same or similar day type, weather condition, and time period as the control target period, and uses the acquired actual supply and demand information as Statistical processing is performed on the data to obtain supply and demand forecast information. Specifically, the demand forecasting unit 34 obtains a load demand forecast value for the control target period by performing statistical processing on the past power demand actual values for the control target period. The demand forecasting unit 34 performs statistical processing of the past renewable energy output actual values of the control target period to obtain a renewable energy output forecast value of the control target period. The demand forecasting unit 34 performs statistical processing on the past actual value of the power flow in the control target period to obtain the power flow prediction value in the control target period. The demand forecasting unit 34 performs statistical processing of past generator output actual values during the control target period to obtain an own-system generator output forecast value for the control target period. The renewable energy output prediction value is the amount of power generated by the power-generating DER connected to the distribution system 100 . The inter-connected power flow is the net amount of electric power that is exchanged between the own system and the other system in which the VPP aggregator 3 controls supply and demand.

The required controllability estimating unit 35 uses the load demand forecast value predicted by the demand forecasting unit 34, the renewable energy output forecast value, the other grid interconnection power flow forecast value, and the own system generator output forecast value in the control target period Based on the supply and demand forecast within the own system, the control power, which is the amount of electric power to be commanded to all the first DERs 6a to be managed and required for supply and demand control, is estimated. Specifically, the required controllability estimating unit 35 expresses all of the load demand forecast value, the renewable energy output forecast value, the other system interconnection power flow forecast value, and the own system generator output forecast value as absolute values, When the system-interconnected power flow going out from the self-system to the other system is positive, the controllability is represented by the following equation (1).
Flexibility = load demand - renewable energy output + power flow connected to other grids - generator output in own system (1)

The DER control command value determination unit 36 sets the adjustment power for supply and demand control in the distribution system 100 during the control target period to the first DER 6a so that the operation cost is minimized within the active power control range of the first control command information. , and generates a first control command value that defines, for each of the first DER 6a, the active power control amount, which is the distributed control power, and the output timing. Specifically, the DER control command value determination unit 36 solves the optimization problem of minimizing the operation cost represented by the objective function under the constraint that the active power control amount of each first DER 6a is within the active power control range. Thus, the active power control amount to be commanded to the first DER 6a, which is the power amount in which the control power is distributed to each first DER 6a, is determined. When the first DER 6a includes a storage battery or an electric vehicle, the active power control amount is the charge amount or the discharge amount. quantity. In one example, the DER control command value determination unit 36 solves an optimization problem for minimizing the operation cost using information that associates the operation cost with the charge amount and discharge amount in each first DER 6a. In addition, the DER control command value determination unit 36 determines output plan information that defines which first DER 6a is to output what amount of active power at which timing in the control target period. The output plan information is information that defines the control timing for outputting the determined active power amount to each first DER 6a, and in one example, is generated for each first DER 6a. The DER control command value determining unit 36 uses the output plan information generated for each first DER 6a as the first control command value. The DER control command value determining section 36 corresponds to the control command value determining section.

FIG. 5 is a diagram schematically showing an example of a configuration of a power distribution automation system provided in the DER management system according to Embodiment 1. FIG. The distribution automation system 4 is, for example, a device that manages the voltage and current in the grid of the power company, and manages the voltage and current of the second DER 6b connected to the distribution grid 100 . The distribution automation system 4 includes a communication unit 41 , a DER controllable amount collection unit 42 , a storage unit 43 , and a DER control command value setting unit 44 .

The communication unit 41 communicates with the second DER 6 b and the DER management device 2 via the communication networks 72 and 73 . In one example, the communication unit 41 receives the second controllable power amount from each second DER 6b. The communication unit 41 transmits the second controllable power amount of each second DER 6 b collected by the DER controllable amount collecting unit 42 to the DER management device 2 . Also, the communication unit 41 receives the second control command information for each second DER 6b from the DER management device 2 . The communication unit 41 transmits the second control command value including the reactive power control amount and the set value included in the second control command information to each second DER 6b according to the instruction from the DER control command value setting unit 44 .

The DER controllable amount collecting unit 42 collects the second controllable power amount from the second DER 6b for each control target period. The DER controllable amount collecting unit 42 stores the collected second controllable power amount in the storage unit 43 .

The storage unit 43 stores the second controllable power amount collected by the DER controllable amount collecting unit 42 . The storage unit 43 also stores system information of the distribution system 100 and load power generation record information. The grid information is information that indicates how voltage and current are distributed in the grid. The load power generation record information is information indicating the actual values of the load demand amount and the power generation amount of the consumer 7 having the second DER 6b. The load power generation record information includes, for example, power record information including past record values of the amount of power demanded by the load 5 and record values of the amount of power output by the DER capable of generating power, as well as types of days, weather conditions, and time zones. This is information in which the power generation status information is associated with the power generation status information. The load power generation performance information is acquired from the DER management device 2, for example.

The DER control command value setting unit 44 generates a second control command value including a reactive power control amount and a set value to be set for each second DER 6b from the second control command information received from the DER management device 2 . The DER control command value setting unit 44 sets a second control command value to each second DER 6b via the communication unit 41 .

Next, details of processing in the DER management device 2 will be described. 6 and 7 are flowcharts showing an example of the procedure of the DER management method according to the first embodiment. The DER management method includes a control instruction information calculation method executed by the DER management device 2 . First, the communication unit 21 receives the first controllable power amount for the first DER 6a from the VPP aggregator 3 (step S11), and receives the second controllable power amount for the second DER 6b from the power distribution automation system 4 (step S12). ).

Next, the prediction unit 23 predicts the load demand amount prediction value of the load 5 connected to the distribution system 100 and the power generation amount prediction value of the power-generating DER in the control target period (step S13). The prediction unit 23 uses the actual value of the load demand and the actual value of the power generation profile stored in the storage unit 22 to predict the predicted load demand amount and the predicted power generation amount in the control target period. After that, the prediction unit 23 estimates the voltage-current distribution in the distribution line 103 of the distribution system 100 using the load demand amount prediction value and the power generation amount prediction value (step S14).

Next, the optimum power flow calculation unit 24 controls the distribution line 103 in which the power system constraint violation does not occur, and calculates the effective power for the first DER 6a so that the power system constraint is observed with respect to the estimated voltage-current distribution. A control range is calculated, and a reactive power control amount is calculated for the second DER 6b. Specifically, the optimum power flow calculation unit 24 uses the first controllable power amount and the second controllable power amount as variables, and under the constraint condition that the power system constraint is observed for the estimated voltage current distribution, , to maximize the amount of discharge in the first DER 6a and minimize the amount of reactive power in the second DER 6b that has the effect of voltage drop (step S15). In addition, the optimum power flow calculation unit 24 uses the first controllable power amount and the second controllable power amount as variables, and the first DER 6a and solve the second optimization problem of minimizing the reactive power amount of the second DER 6b, which has the effect of increasing the voltage (step S16).

FIG. 8 is a diagram schematically showing an example of the configuration of a power distribution system. Here, a case is shown in which two voltage regulators SVRs 91a and 91b are connected to a distribution line 103, and two DERs 6c and 6d are provided in the distribution line 103 between the SVRs 91a and 91b.

9 is a diagram showing an example of voltage distribution in the distribution system shown in FIG. 8. FIG. The horizontal axis in FIG. 9 indicates the position on the distribution line 103 shown in FIG. 8, and the vertical axis indicates the voltage. Here, the position of DER6c is Pc and the position of DER6d is Pd. In FIG. 9, the graph G11 shows, for example, the voltage distribution of the distribution system 100 estimated by the prediction unit 23 in step S12, and assumes that it is in a pre-control state. The interconnection point voltage at the point where each DER 6c, 6d is interconnected with the system, that is, the distribution line 103, must fall within the range determined by the power system restrictions. Assume that the lower limit value of this defined range is V1 and the upper limit value is V2. The charge/discharge amounts of DER 6c and DER 6d are controlled such that graph G11 exists between lower limit value V1 and upper limit value V2. The control amount of each DER including the first DER 6a and the second DER 6b is determined such that the current distribution in the distribution system is such that the current flowing through each line is smaller than the maximum allowable value.

In steps S15 and S16, for the voltage and current distributions before control, the discharge amount and charge amount that can be output within the range where the power system constraints are observed are calculated by the first optimization problem and the second optimization problem, respectively. FIG. 10 is a diagram showing an example of charge/discharge amounts in each DER of the distribution system shown in FIG. In FIG. 10, the horizontal axis indicates the position on the distribution line 103 shown in FIG. 8, and the vertical axis indicates the active power. If the active power is positive it indicates charging, if negative it indicates discharging.

The maximum value of the discharge amount of the first DER 6a and the minimum value of the first reactive power amount of the second DER 6b that has the effect of voltage drop are obtained by solving the first optimization problem. In the example of FIG. 10, the maximum value of the discharge amount of the DER 6c is PC1, and the maximum value of the discharge amount of the DER 6d is PC2. Also, the maximum value of the charge amount of the first DER 6a and the minimum value of the second reactive power amount of the second DER 6b that has the effect of increasing the voltage are obtained by solving the second optimization problem. In the example of FIG. 10, the maximum charge amount of the DER 6c is PD1, and the maximum charge amount of the DER 6d is PD2.

Returning to FIG. 7, the optimum power flow calculator 24 determines an active power control range in which the maximum discharge amount is the lower limit and the maximum charge amount is the upper limit for each first DER 6a (step S17). The optimum power flow calculator 24 determines reactive power control amounts including the first reactive power amount and the second reactive power amount for each second DER 6b (step S18).

The optimum power flow calculation unit 24 calculates the voltage distribution when the discharge amount in the distribution line 103 is maximized from the calculated maximum discharge amount of each first DER 6a (step S19), and calculates the calculated charge amount of each first DER 6a. From the maximum value of , the voltage distribution when the amount of charge in the distribution line 103 is maximized is calculated (step S20).

After that, the DER control command value calculation unit 25 uses the voltage distribution when the discharge amount is maximized, the voltage distribution when the charge amount is maximized, and the reactive power control amount to obtain the set value for the second DER 6b. is calculated (step S21).

Here, a specific example of calculation of the setting value will be described. FIG. 11 is a diagram showing an example of voltage control in the second DER. In this figure, the horizontal axis indicates the voltage of the second DER 6b in one example, and the vertical axis indicates the reactive power output Q. FIG. The dead zone is a voltage range between the lower limit voltage value VL and the upper limit voltage value VU, and when the voltage of the second DER 6b exists within this range, reactive power control is not performed. Reactive power control of the second DER 6b by causing the second DER 6b to output reactive power corresponding to the voltage of the second DER 6b when the voltage of the second DER 6b is less than the lower limit voltage value VL or greater than the upper limit voltage value VU. is done. Therefore, the lower limit voltage value VL and the upper limit voltage value VU are also referred to as control start voltages. Also, the average value of the lower limit voltage value VL and the upper limit voltage value VU, or the voltage value VT through which the vertical axis passes in FIG. 11, is referred to as a control target value. The dead band indicates a target range within which the voltage of the second DER 6b is contained, centering on the control target value.

When the voltage of the second DER 6b exceeds VQ1 or falls below VQ2, the output amount of reactive power becomes a constant value. That is, the reactive power that can be output by the second DER 6b has upper and lower limits. For the upper and lower limit values, the first reactive power amount and the second reactive power amount calculated by the optimum power flow calculation unit 24 may be used, or the upper and lower limit values of the second controllable power amount of the second DER 6b may be used. good too. Various known methods can be used for determining the slope and the gain, and they are not limited.

Assume that the DER 6c in FIG. 8 is the second DER 6b, that is, a DER having a voltage regulation function. When the control by the DER management device 2 is not performed, the distribution line 103 has a voltage distribution as shown in the graph G11 of FIG. Further, as described above, when the charge amount of each DER 6c, 6d is controlled to the maximum value, the voltage distribution shown in the graph G12 is obtained, and the discharge amount of each DER 6c, 6d is maximized. When controlled, the voltage distribution shown in graph G13 is obtained. At this time, the voltage value of the graph G12 at the position Pc of the DER 6c, that is, the connection point voltage at the connection point between the DER 6c and the distribution system 100 is set to the lower limit voltage value VL of the dead band, and the voltage value of the graph G13, that is, the DER 6c and The interconnection point voltage at the interconnection point with the distribution system 100 is set to the upper limit voltage value VU of the dead zone. That is, the region between the lower limit voltage value VL and the upper limit voltage value VU is the dead zone. An average value of the lower limit voltage value VL and the upper limit voltage value VU is set as the target voltage VT. The DER control command value calculator 25 calculates the lower limit voltage value VL, the upper limit voltage value VU, and the target voltage VT as described above, and uses them as set values.

Returning to FIG. 7, the DER control command value calculation unit 25 generates first control command information that associates the first DER 6a with the active power control range, and associates the second DER 6b with the reactive power control amount and the set value. Second control command information is generated (step S22). The communication unit 21 then transmits the first control command information to the VPP aggregator 3 (step S23), and transmits the second control command information to the power distribution automation system 4 (step S24). With this, the processing ends.

In the above description, after step S14, the process proceeds to step S15. However, the voltage-current distribution of the distribution line 103 of the distribution system 100 estimated in step S14 may violate the power system constraints. In this case, the processing from step S15 is performed on the distribution lines 103 whose voltage-current distribution satisfies the power system constraints, and the distribution lines 103 whose voltage-current distribution does not satisfy the power system constraints are subjected to Since the control amount for the purpose of resolving the violation is not secured in form 1, the process ends. That is, even if the optimum power flow calculation unit 24 determines whether the distribution line 103 has a voltage-current distribution that satisfies the power system constraints between steps S14 and S15, good.

Next, processing in the VPP aggregator 3 and the distribution automation system 4 will be explained. 12 is a flowchart illustrating an example of a procedure of command value calculation processing of a VPP aggregator in the DER management system according to Embodiment 1. FIG. First, the communication unit 31 receives the first control command information in which the first DER 6a and the active power control range are associated with each other from the DER management device 2 (step S31).

Next, the demand forecasting unit 34 predicts the load demand forecast value, the renewable energy output forecast value, the other grid interconnection power flow forecast value, and the own system generator output forecast value in the control target period (step S32). After that, the required controllability estimating unit 35 uses the load demand forecast value, the renewable energy output forecast value, the other grid interconnection power flow forecast value, and the own system generator output forecast value to perform supply and demand control in the distribution system 100. Therefore, the control power, which is the amount of electric power that needs to be commanded to all the first DERs 6a to be managed, is estimated (step S33).

Then, within the active power control range of the first DER 6a, an active power control amount is determined, which is the amount of electric power obtained by distributing the control power to each first DER 6a with the aim of minimizing the overall operating cost in the own system. Specifically, the DER control command value determination unit 36 solves the optimization problem of minimizing the operation cost represented by the objective function under the constraint that the active power control amount of each first DER 6a is within the active power control range. . As a result, the DER control command value determination unit 36 determines the active power control amount to be commanded to the first DER 6a, which is the power amount in which the control power is distributed to each of the first DERs 6a (step S34).

In addition, the DER control command value determination unit 36 determines output plan information that defines how much active power is to be output to which first DER 6a at what timing in the control target period, and determines the output plan information for each first DER 6a. The associated first control command value is generated (step S35).

After that, the communication unit 31 transmits the first control command value to each first DER 6a (step S36). The power control device 62 of each first DER 6a controls the distributed energy device 61 based on the first control command value from the VPP aggregator 3, that is, the output plan information. With this, the processing ends.

13 is a flowchart illustrating an example of the procedure of a set value setting process of the power distribution automation system in the DER management system according to Embodiment 1. FIG. First, the communication unit 41 receives the second control command information from the DER management device 2 (step S51). The second control command information is information that associates the second DER 6b with the reactive power control amount and the set value.

Next, the DER control command value setting unit 44 generates a second control command value including a reactive power control amount and a set value to be set for each second DER 6b from the received second control command information for each second DER (step S52). . And the communication part 41 transmits a 2nd control command value to each 2nd DER6b (step S53). The power control device 62 of each second DER 6 b controls the distributed energy device 61 based on the reactive power control amount and set value included in the second control command value received from the distribution automation system 4 . With this, the processing ends.

Next, hardware configuration examples of the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 of the first embodiment will be described. 14 is a diagram illustrating an example of a configuration of a computer system that implements the DER management device, the VPP aggregator, and the power distribution automation system used in the DER management system according to the first embodiment; FIG. The DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 are each realized by a computer system 200 illustrated in FIG. 14, for example.

As shown in FIG. 14, this computer system 200 includes a control section 201, an input section 202, a storage section 203, a display section 204, a communication section 205, and an output section 206, which are connected via a system bus 207. ing. In FIG. 14, the control unit 201 is, for example, a CPU (Central Processing Unit) or the like, and executes a program describing processing in the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 of the first embodiment. Input unit 202 is composed of, for example, a keyboard and a mouse, and is used by the user of computer system 200 to input various types of information. The storage unit 203 includes various memories such as RAM (Random Access Memory) and ROM (Read Only Memory) and storage devices such as a hard disk, and stores programs to be executed by the control unit 201 and necessary information obtained in the course of processing. store data, etc. The storage unit 203 is also used as a temporary storage area for programs. The display unit 204 is configured by a liquid crystal display (LCD) or the like, and displays various screens to the user of the computer system 200 . A communication unit 205 is a receiver and a transmitter that perform communication processing. The output unit 206 is a printer or the like.

Here, an example of the operation of the computer system 200 until the program realizing each of the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 of the first embodiment becomes executable will be described. The computer system 200 configured as described above stores a program from a CD-ROM or DVD-ROM set in a CD (Compact Disc)-ROM drive or a DVD (Digital Versatile Disc)-ROM drive (not shown), for example. 203. Then, the program read from the storage unit 203 is stored in the storage unit 203 when the program is executed. In this state, the control unit 201 executes processing as the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 of the first embodiment according to the programs stored in the storage unit 203. FIG.

In the above description, a program describing processing is provided using a CD-ROM or DVD-ROM as a recording medium. Accordingly, for example, a program provided via a transmission medium such as the Internet via communication unit 205 may be used.

The communication unit 21 shown in FIG. 3 is realized by the communication unit 205 shown in FIG. 14, for example. The communication unit 31 shown in FIG. 4 is realized by the communication unit 205 shown in FIG. 14, for example. The communication unit 41 shown in FIG. 5 is realized by the communication unit 205 shown in FIG. 14, for example. Prediction unit 23, optimum power flow calculation unit 24, and DER control command value calculation unit 25 shown in FIG. 3 are implemented by control unit 201 executing corresponding programs. DER controllable amount collection unit 32, demand prediction unit 34, required control force estimation unit 35, and DER control command value determination unit 36 shown in FIG. 4 are implemented by control unit 201 executing a corresponding program. The DER controllable amount collecting unit 42 and the DER control command value setting unit 44 shown in FIG. 5 are implemented by the control unit 201 executing corresponding programs. The storage unit 203 is also used when the control unit 201 executes the program.

The storage unit 22 shown in FIG. 3 is implemented by the storage unit 203 shown in FIG. Storage unit 33 shown in FIG. 4 is implemented by storage unit 203 shown in FIG. Storage unit 43 shown in FIG. 5 is realized by storage unit 203 shown in FIG.

Further, each of the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 of Embodiment 1 may be realized by one computer system 200, or may be realized by a plurality of computer systems 200. . For example, the DER management device 2 may be realized by a cloud system. Also, the DER management device 2 may be realized by one computer system 200 .

The DER management program of Embodiment 1, for example, causes the computer system 200 to comply with the voltage and current distribution of the distribution system 100 based on the supply and demand forecast, and the first DER 6a in the control target period. a step of calculating an active power control range determined by the maximum value of the charge amount and the discharge amount that can be output within the controllable first controllable power amount range of , and each of the plurality of first DERs 6a and the active power control range The step of generating the associated first control command information and the step of transmitting the first control command information to the VPP aggregator 3 that determines the active power amount to be commanded to the plurality of first DERs 6a for supply and demand adjustment are executed. .

In the first embodiment, the DER management device 2 uses the first controllable power amount in the first DER 6a as a variable, and the power system constraint of the distribution system 100 is applied to the voltage current distribution obtained by the supply and demand prediction of the distribution system 100. of the amount of discharge obtained by solving a first optimization problem whose objective function maximizes the amount of discharge in the first DER 6a, and a second optimization problem whose objective function maximizes the amount of charge in the first DER 6a. The active power control range with the maximum value as the lower limit and the maximum value of the charge amount as the upper limit is output to the VPP aggregator 3 as first control command information. As a result, in order to adjust the supply and demand of the distribution system 100, the range of the active power control amount of each first DER 6a, that is, the charge/discharge range allowed by each first DER 6a is set to VPP while satisfying the constraints on the voltage and current of the distribution system 100. It has the effect that it can be provided to the aggregator 3 . As a result, the VPP aggregator 3 distributes the active power control amount commanded to each first DER 6a for supply and demand control in the distribution system 100 within the allowable charge/discharge range of each first DER 6a for the purpose of minimizing the operation cost. can decide. By controlling the first DER 6 a with the determined active power control amount, the VPP aggregator 3 can adjust the power supply and demand and suppress the occurrence of voltage and current violations in the distribution system 100 .

Further, when the distribution system 100 is further provided with a second DER 6b that is a DER having a voltage adjustment function, the DER management device 2 adjusts the voltage and current distribution of the distribution system 100 to A first optimization problem in which the objective function maximizes the discharge of the first DER 6a and minimizes the reactive energy of the second DER 6b, which has the effect of voltage drop, so that the power system constraints are observed, and the objective function is the first DER 6a Solve a second optimization problem to maximize the amount of charge and minimize the amount of reactive power in the second DER 6b that has the effect of boosting the voltage. Then, the DER management device 2 transmits to the VPP aggregator 3 as first control command information an active power control range in which the maximum value of the discharged amount is the lower limit and the maximum value of the charged amount is the upper limit. In addition, the DER management device 2 uses the first reactive power amount, which is the minimum value of the reactive power amounts of the second DERs 6b that have the effect of voltage drop, and the minimum value of the reactive power amounts of the second DERs 6b that has the effect of increasing the voltage. A certain second reactive power amount and a setting value for controlling the power output from the second DER 6b with the reactive power are calculated, and these are output to the power distribution automation system 4 as second control command information. As a result, even when the second DER 6b is provided in the system, it is possible to adjust the supply and demand of the distribution system 100 while satisfying the constraints on the voltage and current of the distribution system 100 .

Embodiment 2.
In Embodiment 1, the prediction unit 23 of the DER management device 2 predicts one power generation amount prediction value in the control target period of the DER 6 connected to the distribution system 100 . In Embodiment 2, a case will be described in which the prediction unit 23 of the DER management device 2 predicts two power generation amount prediction values in the control target period of the DER 6 connected to the distribution system 100 .

The configurations of the DER management system 1, the DER 6, the DER management device 2, the VPP aggregator 3, and the power distribution automation system 4 according to the second embodiment are the same as those described in the first embodiment, so description thereof will be omitted. However, the functions of the DER management device 2 are different from those of the first embodiment. Below, portions different from the first embodiment will be described.

In Embodiment 2, the prediction unit 23 of the DER management device 2 predicts the demand for the load 5 connected to the distribution system 100 during the control target period and Predicting the maximum value and minimum value of the power generation amount in the control target period of the power-generating DER. Hereinafter, the maximum and minimum values of the power generation amount in the control target period are referred to as the maximum predicted power generation amount and the minimum predicted power generation amount, respectively. In Embodiment 1, one value is predicted as a power generation amount prediction value for DER that can be generated, but in Embodiment 2, two values are predicted.

In the second embodiment as well, the prediction unit 23 predicts the load demand prediction value, the power generation maximum prediction value, and the power generation minimum prediction value using the actual value of the load demand and the actual value of the power generation profile. Since the prediction of the load demand prediction value has been explained in the first embodiment, the explanation thereof will be omitted here, and a specific example of the prediction of the maximum predicted value of the power generation amount and the minimum predicted value of the power generation amount will be described. The prediction unit 23 acquires the actual value of the power generation profile for the period corresponding to the control target period from the load power generation performance information, and sets the power generation profile with the largest power generation amount among them as the maximum power generation amount predicted value. Similarly, the prediction unit 23 sets the power generation profile with the smallest power generation amount among the acquired actual values of the power generation profiles as the minimum power generation amount predicted value. Alternatively, the prediction unit 23 predicts the estimated amount of power generation based on weather conditions such as solar radiation and wind volume that are the same as or similar to the period to be controlled to be predicted, and actual values of power generation profiles of DERs that can generate power in the past. Among them, the power generation amount with the highest output may be set as the maximum power generation amount predicted value, and the power generation amount with the lowest output may be set as the power generation amount minimum prediction value.

In addition, the prediction unit 23 uses the load demand prediction value for the control target period and the maximum and minimum power generation amount prediction values of the power-generating DER to determine when the power-generating DER is the maximum output and when the power generation is the minimum output. Estimate the voltage-current distribution of the distribution system 100 in each of the cases.

The optimum power flow calculation unit 24 of the DER management device 2 observes the power system constraints of the distribution system 100, and from the voltage and current distribution of the distribution system 100 based on the supply and demand prediction that the DER that can be generated in the control target period becomes the maximum output, The distribution system 100 based on the supply and demand forecast where the maximum discharge amount that can be output within the range of the first controllable power amount that can be controlled by the first DER 6a during the control target period and the minimum output of the DER that can be generated during the control target period. From the voltage-current distribution of , calculate the maximum value of the charge amount that can be output within the range of the first controllable power amount in the control target period, and determine the active power control range determined by the maximum values of the discharge amount and the charge amount. do.

Specifically, with the first controllable power amount and the second controllable power amount as variables, the constraint condition that the power system constraint is observed with respect to the voltage current distribution when the DER that can be generated is the maximum output. Below, we solve a third optimization problem to maximize the amount of discharge in the first DER 6a and minimize the amount of reactive power in the second DER 6b that has the effect of voltage drop. In addition, the optimum power flow calculation unit 24 uses the first controllable power amount and the second controllable power amount as variables, and the power system constraints are observed with respect to the voltage current distribution when the DER that can be generated is the minimum output. A fourth optimization problem is solved to maximize the amount of charge in the first DER 6a and minimize the amount of reactive power in the second DER 6b, which has the effect of increasing the voltage, under the constraint of .

By solving the third optimization problem, the maximized discharge amount of each first DER 6a and the minimized first reactive energy amount of each second DER 6b with voltage drop effect are obtained. By using the maximized discharge amount of each first DER 6a in the distribution line 103, the voltage-current distribution when the discharge amount is maximized is obtained. By solving the fourth optimization problem, the maximized charge amount of each first DER 6a and the minimized second reactive power amount of each second DER 6b that has the effect of raising the voltage are obtained. By using the maximized charge amount of each first DER 6a in the distribution line 103, the voltage-current distribution when the charge amount is maximized is obtained.

Next, details of processing in the DER management device 2 will be described. 15 is a flowchart illustrating an example of the procedure of the DER management method according to the second embodiment; FIG. First, the communication unit 21 receives the first controllable power amount for the first DER 6a from the VPP aggregator 3 (step S71), and receives the second controllable power amount for the second DER 6b from the power distribution automation system 4 (step S72). ).

Next, the prediction unit 23 predicts the load demand prediction value of the load 5 connected to the distribution system 100 in the control target period using the actual value of the load demand (step S73). In addition, the prediction unit 23 predicts the maximum predicted power generation amount and the minimum predicted power generation amount of DERs that can generate power connected to the distribution system 100 during the control target period using the actual values of the power generation profile (step S74). . Here, the maximum predicted power generation amount of the DER that can be generated refers to the maximum amount of DER that can be generated that is predicted from the actual value of the power generation profile in the control target period. Further, the minimum predicted power generation amount of power-generating DER means the minimum power generation amount of power-generating DER predicted from the actual value of the power generation profile in the control target period.

After that, the prediction unit 23 estimates the voltage-current distribution at the time of maximum power generation, which is the voltage-current distribution in the distribution line 103 of the distribution system 100, using the load demand amount prediction value and the power generation maximum prediction value (step S75). The voltage-current distribution at the time of maximum power generation corresponds to the first voltage-current distribution. Also, the prediction unit 23 estimates the voltage-current distribution at the time of the minimum power generation, which is the voltage-current distribution in the distribution line 103 of the distribution system 100, using the load demand amount prediction value and the power generation minimum prediction value (step S76). The voltage-current distribution at the time of minimum power generation corresponds to the second voltage-current distribution.

16 is a diagram showing an example of voltage distribution in the power distribution system shown in FIG. 8. FIG. The horizontal axis of FIG. 16 indicates the position on the distribution line 103 of the distribution system 100 shown in FIG. 8, and the vertical axis indicates the voltage. In FIG. 16, the graph G21 indicates the voltage distribution at the time of maximum power generation estimated in step S75, and assumes that it is in a state before control. Graph G22 shows the voltage distribution at the time of minimum power generation estimated in step S76, and assumes that it is in a pre-control state.

Returning to FIG. 15, the optimum power flow calculation unit 24 controls the distribution line 103 in which the power system constraint violation does not occur, uses the first controllable power amount and the second controllable power amount as variables, and estimates the power generation amount A third optimum that maximizes the discharge amount of the first DER 6a and minimizes the reactive power amount of the second DER 6b that has the effect of voltage drop under the constraint that the power system constraint is observed for the maximum voltage-current distribution. solve the transformation problem (step S77). In addition, the optimum power flow calculation unit 24 controls the distribution line 103 in which no power system constraint violation has occurred, uses the first controllable power amount and the second controllable power amount as variables, and estimates the voltage at the minimum power generation amount A fourth optimization problem of maximizing the charge amount of the first DER 6a and minimizing the reactive power amount of the second DER 6b, which has the effect of increasing the voltage, under the constraint that the power system constraint is observed for the current distribution. Solve (step S78).

After that, the same procedure as the procedure shown in steps S17 to S24 in FIG. 7 of the first embodiment is executed. That is, the optimum power flow calculation unit 24 determines the active power control range for the first DER 6a, and calculates the reactive power control amount including the first reactive power amount and the second reactive power amount and the setting value for the second DER 6b. The DER control command value calculation unit 25 generates first control command information in which the first DER 6a is associated with the active power control range, and second control command information in which the second DER 6b is associated with the reactive power control amount and the set value. to generate The communication unit 21 then transmits the first control command information and the second control command information to the VPP aggregator 3 and the power distribution automation system 4, respectively.

The voltage distribution at the time of maximum power generation calculated in step S75 is shown in graph G23 of FIG. 16, and the voltage distribution at time of minimum power generation calculated in step S76 is shown in graph G24 of FIG. Further, assuming that the DER 6c in FIG. 8 is the second DER 6b, that is, the DER having the voltage adjustment function, the set value of the DER 6c is calculated in the same manner as in the first embodiment. That is, the voltage value of the graph G24 at the position Pc of the DER 6c is set to the lower limit voltage value VL of the dead band, and the voltage value of the graph G23 is set to the upper limit voltage value VU of the dead band. An average value of the lower limit voltage value VL and the upper limit voltage value VU is set as the target voltage VT. Then, the DER control command value calculator 25 sets the lower limit voltage value VL, the upper limit voltage value VU, and the target voltage VT as set values.

The same effects as in the first embodiment can also be obtained in the second embodiment.

Embodiment 3.
In the first and second embodiments, the DER management device 2 acquires actual values, which are past data of load demand and power generation profile in the distribution system 100, from the storage unit 22, and estimates the voltage-current distribution of the distribution system 100. was However, the estimation of the voltage-current distribution of the distribution system 100 is not limited to that shown in the first and second embodiments. Embodiment 3 describes a case where the voltage-current distribution of the distribution system 100 is estimated by another method.

FIG. 17 is a diagram schematically showing an example of a configuration of a DER management system according to Embodiment 3; The same reference numerals are given to the same components as in the first embodiment, and the description thereof is omitted. The DER management system 1 a according to Embodiment 3 further includes a measuring device 8 for each distribution line 103 . The measuring device 8 is a device that measures the state quantity of the distribution system 100 . The state quantity of the power distribution system 100 may be anything that can calculate the voltage-current distribution of the power distribution line 103 . Examples of state quantities of the distribution system 100 are line voltage, phase voltage, line current, power factor, passing active power, and passing reactive power. The measuring device 8 transmits the measured state quantity of the power distribution amount to the DER management device 2a via the communication network 81 as the distribution system state quantity information. In one example, the measuring device 8 is provided on the distribution line 103 on the distribution transformer 101 side.

In the third embodiment, the configurations of the DER 6, the VPP aggregator 3 and the power distribution automation system 4 are the same as those described in the first embodiment, but the configuration of the DER management device 2a is different from that of the first embodiment. 18 is a diagram schematically illustrating an example of a configuration of a DER management device according to Embodiment 3; FIG. The same reference numerals are given to the same components as in the first embodiment, and the explanation thereof is omitted, and the different parts from the first embodiment are explained. The DER management device 2a includes a measurement information collection unit 26 instead of the prediction unit 23 in the configuration of the first embodiment. The communication unit 21 also has a function of communicating with the measuring device 8 . The communication unit 21 receives the distribution system state quantity information from the measuring device 8 .

The measurement information collection unit 26 collects the distribution system state quantity information from the measuring device 8 via the communication unit 21 and stores the collected distribution system state quantity information in the storage unit 22 together with the collection time. The measurement information collecting unit 26 also uses the distribution system state quantity information stored in the storage unit 22 to estimate the voltage-current distribution of the distribution line 103 of the distribution system 100 during the control target period. That is, in the third embodiment, the distribution system state quantity information measured by the measuring device 8 is used for estimating the voltage-current distribution of the distribution system 100 . In one example, the measurement information collecting unit 26 estimates the voltage-current distribution of the distribution system 100 in the control target period using the past data obtained by measuring the state quantities related to the voltage-current distribution of the distribution system 100 .

Next, details of processing in the DER management device 2a will be described. 19 is a flowchart illustrating an example of the procedure of the DER management method according to the third embodiment; FIG. In FIG. 19, the same step numbers are assigned to the same processes as in FIG. 6 of Embodiment 1, and the description thereof is omitted. Below, a part different from FIG. 6 is demonstrated.

Along with receiving the first controllable power amount and the second controllable power amount in steps S11 and S12, the measurement information collection unit 26 collects distribution system state quantity information from the measurement device 8 via the communication unit 21 ( step S91). The collected distribution system state quantity information is stored in the storage unit 22 together with the collected time.

Next, the measurement information collecting unit 26 estimates the voltage-current distribution in the control target period using the distribution system state quantity information of the period corresponding to the control target period (step S92). After that, the process moves to the process after step S15 in FIG.

In the third embodiment, the DER management device 2a collects from the measuring device 8 the distribution system state quantity information that can calculate the voltage-current distribution of the distribution line 103, and uses the distribution system state quantity information to determine the control target period , the voltage-current distribution of the distribution line 103 is estimated. In the first embodiment, the predicted load demand and the predicted power generation are predicted from the actual load demand and the actual power generation profile, and the voltage and current distribution in the distribution line 103 is calculated from the predicted load demand and the predicted power generation. was estimated. However, in the third embodiment, since the voltage-current distribution of the distribution line 103 is estimated from the distribution system state quantity information, the number of processing steps required for estimating the voltage-current distribution is reduced compared to the first embodiment. has the effect of being able to

Embodiment 4.
In the third embodiment, the example of calculating the voltage-current distribution of the distribution system 100 using the distribution system state quantity information measured by the measuring device 8 is applied to the first embodiment. In the fourth embodiment, an example of calculating the voltage-current distribution of the distribution system 100 using the past distribution system state quantity information measured by the measuring device 8 is applied to the second embodiment.

The configurations of the DER management system 1a, DER 6, DER management device 2a, VPP aggregator 3, and power distribution automation system 4 according to Embodiment 4 are the same as those described in Embodiments 1 to 3, so description thereof will be omitted. do. In the following, portions different from Embodiments 1 to 3 will be described.

In the fourth embodiment, the measurement information collection unit 26 of the DER management device 2a uses the past distribution system state quantity information stored in the storage unit 22 to estimate that the DER that can be generated during the control target period is the maximum output. The voltage-current distribution at the maximum amount of power generation when the output is assumed to be the minimum output and the voltage-current distribution at the minimum amount of power generation when the minimum output is estimated are calculated. Specifically, the measurement information collecting unit 26 collects the data representing the maximum output and the data representing the minimum output from the past distribution system state quantity information for the period corresponding to the control target period for the power-generating DER. Extract. For the chargeable/dischargeable DER, the output is predicted using the past distribution system state quantity information for the period corresponding to the control target period. When extracting data with the maximum output and minimum output of DER that can be generated, and when predicting the output of DER that can be charged and discharged, using the same or similar weather conditions as the control target period, Past distribution system state quantity information may be narrowed down. In this case, the distribution system state quantity information includes day types, weather conditions, and time zones. Then, the voltage-current distribution at the maximum power generation amount and the maximum power generation amount of the distribution line 103 are obtained using the extracted data of the maximum output and minimum output of the DER capable of generating power and the output of the chargeable/dischargeable DER. Calculate the small time voltage-current distribution.

Next, details of processing in the DER management device 2a will be described. FIG. 20 is a flow chart showing an example of the procedure of the DER management method according to the fourth embodiment. In FIG. 20, the same step numbers are given to the same processes as in FIG. 15 of the second embodiment, and the description thereof is omitted. In the following, portions different from FIG. 15 will be described.

Along with receiving the first controllable power amount and the second controllable power amount in steps S71 and S72, the measurement information collection unit 26 collects distribution system state quantity information from the measurement device 8 via the communication unit 21 ( step S111). The collected distribution system state quantity information is stored in the storage unit 22 together with the collected time.

Next, the measurement information collection unit 26 uses the past distribution system state quantity information to obtain the maximum output and minimum output of DER that can be generated in the period corresponding to the control target period, and the output of DER that can be charged and discharged. Predict (step S112). After that, the measurement information collecting unit 26 estimates the voltage-current distribution at the maximum power generation amount of the distribution system 100 using the predicted maximum power-generating DER output and chargeable/dischargeable DER output (step S113). In addition, the measurement information collection unit 26 estimates the voltage-current distribution at the time of the minimum power generation amount of the distribution system 100 using the predicted minimum power-generating DER output and the chargeable/dischargeable DER output (step S114). After that, the process proceeds to the process after step S77 in FIG.

The same effects as those of the third embodiment can also be obtained in the fourth embodiment.

Embodiment 5.
Embodiment 5 describes modifications of Embodiments 1 to 4 described above. In the following description, the same reference numerals are assigned to the same components as those described above, and the description thereof will be omitted, and the different parts will be described.

In Embodiments 1 to 4, the DER management devices 2 and 2a transmit the reactive power control amount and the setting value to the distribution automation system 4, and the distribution automation system 4 sets the reactive power control amount and the setting value in the second DER 6b. rice field. The DER management device 2 may execute the process of setting the reactive power control amount and the set value in the second DER 6b.

21 is a diagram schematically illustrating an example of a configuration of a DER management device according to Embodiment 5. FIG. The DER management device 2b further includes a DER control command value setting unit 27 in FIG. 3 of the first embodiment. The DER control command value setting unit 27 generates a second control command value in which the reactive power control amount and the set value are associated with each second DER 6b from the second control command information, and sets the second control command value to the second DER 6b. do. The DER control command value setting section 27 corresponds to the control command value setting section.

FIG. 22 is a diagram schematically showing an example of a configuration of a power distribution automation system according to Embodiment 5. FIG. As shown in FIG. 22, the power distribution automation system 4a has a configuration in which the DER control command value setting unit 44 is removed from FIG. 5 of the first embodiment. This is because the power distribution automation system 4a does not set the reactive power control amount and the set value for the second DER 6b.

21 and 22 show an example in which the distribution automation system 4a does not set the reactive power control amount and the set value for the second DER 6b, but the distribution automation system 4 may be removed from the DER management systems 1 and 1a. FIG. 23 is a diagram schematically showing an example of a configuration of a DER management system according to Embodiment 5. FIG. The DER management system 1b of FIG. 23 has a configuration in which the power distribution automation system 4 is removed from FIG. 1 of the first embodiment. In this case, the DER controllable amount collection unit 32 of the VPP aggregator 3 further has a function of collecting the second controllable amount of power from the second DER 6 b and transmitting it to the DER management device 2 . The communication unit 21 of the DER management device 2 further has a function of transmitting to the VPP aggregator 3 second control command information indicating the reactive power control amount and set value for each second DER 6b. The DER control command value determining unit 36 of the VPP aggregator 3 generates a second control command value in which the reactive power control amount and the set value are associated with each second DER 6b from the second control command information, and determines the second control command value. It further has a function of setting to the second DER 6b. In this way, when the power distribution automation system 4 is not present, the functions of the power distribution automation system 4 can be delegated to the VPP aggregator 3 . Also, the DER management device 2b described with reference to FIG. 21 may be provided in the DER management system 1b of FIG. That is, the communication unit 21 of the DER management device 2b does not transmit the second control command information to the VPP aggregator 3, and the DER control command value setting unit 27 transmits the second control command value generated from the second control command information to each It may be set to the second DER 6b.

In the above description, the configuration of Embodiment 1 was taken as an example, but similar modifications can be applied to the configurations of Embodiments 2 to 4 as well.

In the above description, the voltage-current distribution is estimated by the prediction unit 23 or the measurement information collection unit 26 of the DER management devices 2, 2a, 2b. The estimated voltage-current distribution may be acquired from the outside without having the measurement information collecting unit 26 . 24 is a diagram schematically showing another example of the configuration of the DER management system according to Embodiment 5. FIG. The DER management system 1 c of FIG. 24 further comprises a prediction system 9 connected to the communication network 73 . The prediction system 9 is a device having the function of the prediction unit 23 of the DER management device 2 of the first and second embodiments. That is, the prediction system 9 holds actual load power generation information including the actual value of the load demand connected to the distribution system 100 and the actual value of the power generation profile, and based on the actual load power generation information, the distribution system 100 during the control target period. , and estimates the voltage-current distribution in the distribution line 103 of the distribution system 100 in the control target period based on the prediction result. The prediction system 9 then transmits the voltage-current distribution to the DER management device 2c.

25 is a diagram schematically showing another example of the configuration of the DER management device according to the fifth embodiment; FIG. As shown in FIG. 25, the DER management device 2c has a configuration in which the prediction unit 23 is removed from FIG. 3 of the first embodiment. The optimum power flow calculator 24 uses the voltage-current distribution obtained from the prediction system 9 to perform processing for determining the active power control range and the reactive power control amount.

Note that the prediction system 9 may have the function of the measurement information collection unit 26 described in the third and fourth embodiments. In this case, the prediction system 9 collects the distribution system state quantity information from the measuring device 8 via the communication unit, and stores the collected distribution system state quantity information together with the collection time in the storage unit. The prediction system 9 also estimates the voltage-current distribution in the distribution line 103 of the distribution system 100 during the control target period using the distribution system state quantity information stored in the storage unit. The prediction system 9 then transmits the voltage-current distribution to the DER management device 2c. By causing the prediction system 9 to estimate the voltage-current distribution in this way, it is possible to reduce the processing load on the DER management device 2c.

The configurations shown in the above embodiments are only examples, and can be combined with other known techniques, or can be combined with other embodiments, without departing from the scope of the invention. It is also possible to omit or change part of the configuration.

1, 1a, 1b, 1c DER management system, 2, 2a, 2b, 2c DER management device, 3 VPP aggregator, 4, 4a distribution automation system, 5 load, 6 DER, 6a first DER, 6b second DER, 7 consumer , 8 measurement device, 9 prediction system, 21, 31, 41, 621 communication unit, 22, 33, 43, 623 storage unit, 23 prediction unit, 24 optimum power flow calculation unit, 25 DER control command value calculation unit, 26 measurement information collection unit 27, 44 DER control command value setting unit 32, 42 DER controllable amount collection unit 34 demand prediction unit 35 required adjustment force estimation unit 36 DER control command value determination unit 61 distributed energy device 62 Power control device 71, 72, 73, 81 communication network 100 distribution system 101 distribution transformer 102 busbar 103 distribution line 622 controllable power calculation unit 624 control unit.

Claims (21)

A distributed energy resource management device for calculating an output in a distributed energy resource including a plurality of first distributed energy resources connected to a distribution system and whose output active power is controlled,
Constraints on the voltage and current of the distribution system are observed from the voltage and current distribution of the distribution system based on the supply and demand forecast, and the first distributed energy resource is output within a controllable first power amount range during the control target period. an optimum power flow calculation unit that calculates the maximum possible charge amount and discharge amount and determines an active power control range determined by the maximum charge amount and discharge amount;
a control command value calculator that generates first control command information that associates each of the plurality of first distributed energy resources with the active power control range;
a communication unit that transmits the first control command information to a virtual substation aggregator that determines active power amounts to be commanded to the plurality of first distributed energy resources;
with
The distributed energy resource management apparatus, wherein the active power control range is a control range of the active power output from the first distributed energy resource. the distributed energy resources further include a plurality of second distributed energy resources connected to the distribution system and having voltage regulation capabilities;
The optimum power flow calculation unit is capable of controlling the plurality of second distributed energy resources in the control target period while observing the constraint of the distribution system from the voltage and current distribution in addition to the active power control range. calculating a reactive power control amount that is the minimum value of the reactive power amount that can be output within the range of the second power amount;
The control command value calculation unit associates a set value and the reactive power control amount used for voltage control using reactive power in the plurality of second distributed energy resources with each of the plurality of second distributed energy resources. 2. The distributed energy resource management device according to claim 1, further generating second control command information. A prediction unit for estimating the voltage-current distribution in the control target period using the actual value of load demand in the distribution system and the actual value of the amount of power generated by the distributed energy resource that can generate power. The distributed energy resource management device according to claim 1 or 2. 2. A measurement information collecting unit that collects the state quantity of the distribution system from a measuring device and estimates the voltage current distribution in the control target period using the state quantity of the distribution system. 3. The distributed energy resource management device according to 2. A distributed energy resource management device for calculating an output in a distributed energy resource including a plurality of first distributed energy resources connected to a distribution system and whose output active power is controlled,
From a first voltage and current distribution of the distribution system based on a supply and demand prediction in which the voltage and current constraints of the distribution system are observed in the control target period, and the distributed energy resource capable of generating power in the control target period has the maximum output. a maximum discharge amount that can be output within a controllable first power amount range of the first distributed energy resource during the control target period; From the second voltage and current distribution of the distribution system based on the supply and demand forecast, the maximum value of the charge amount that can be output within the range of the first electric amount in the control target period is calculated, and the discharge amount and the an optimum power flow calculation unit that determines an active power control range determined by the maximum charge amount;
a control command value calculator that generates first control command information that associates each of the plurality of first distributed energy resources with the active power control range;
a communication unit that transmits the first control command information to a virtual substation aggregator that determines active power amounts to be commanded to the plurality of first distributed energy resources;
with
The distributed energy resource management apparatus, wherein the active power control range is a control range of the active power output from the first distributed energy resource. the distributed energy resources further include a plurality of second distributed energy resources connected to the distribution system and having voltage regulation capabilities;
The optimum power flow calculation unit satisfies the constraint of the distribution system from the first voltage-current distribution and the second voltage-current distribution in addition to the active power control range, and performs the plurality of power-flow calculations during the control target period. 2 calculating a reactive power control amount that is the minimum value of the reactive power amount that can be output within the range of the controllable second power amount of the distributed energy resource;
The control command value calculation unit associates a set value and the reactive power control amount used for voltage control by reactive power in the plurality of second distributed energy resources with the plurality of second distributed energy resources. 6. The distributed energy resource management device according to claim 5, further generating 2 control command information. estimating the first voltage-current distribution and the second voltage-current distribution in the control target period using the actual value of the load demand in the distribution system and the actual value of the power generation amount in the power-generating distributed energy resource; 7. The distributed energy resource management device according to claim 5 or 6, further comprising a predictor. A measurement information collecting unit that collects state quantities of the distribution system from a measuring device and estimates the first voltage-current distribution and the second voltage-current distribution in the control target period using the state quantities of the distribution system. 7. The distributed energy resource management device according to claim 5 or 6, characterized in that: distributed energy resources including a plurality of first distributed energy resources connected to a distribution system and controlled in output by active power;
A distributed energy resource management device according to claim 1;
a virtual substation aggregator that determines active power to command the plurality of first distributed energy resources for balancing;
A distributed energy resource management system comprising:
The virtual substation aggregator,
a communication unit that receives the first control command information from the distributed energy resource management device;
a required controllability estimating unit that estimates controllability, which is the amount of electric power required for supply and demand control, based on the supply and demand forecast in the distribution system during the control target period;
distributing the controllability to each of the plurality of first distributed energy resources so as to minimize operating costs within the active power control range of the first control command information; a control command value determination unit that determines a first control command value including an active power control amount that is the distributed control power commanded to each of the energy resources and an output timing;
with
The distributed energy resource management system, wherein the communication unit transmits the first control command value to each of the plurality of first distributed energy resources. the distributed energy resources further include a plurality of second distributed energy resources connected to the distribution system and having voltage regulation capabilities;
The optimum power flow calculation unit of the distributed energy resource management device satisfies the constraint of the distribution system from the voltage-current distribution in addition to the active power control range, and performs the plurality of second calculating a reactive power control amount that is the minimum value of the reactive power amount that can be output within the range of the controllable second power amount of the distributed energy resource;
The control command value calculation unit of the distributed energy resource management device includes a set value used for voltage control by reactive power in the plurality of second distributed energy resources, the reactive power control amount, and the plurality of second distributed energy resources. 10. The distributed energy resource management system according to claim 9, further generating second control command information associated with each of the energy resources. distributed energy resources including a plurality of first distributed energy resources connected to a distribution system and controlled in output by active power;
A distributed energy resource management device according to claim 5;
a virtual substation aggregator that determines active power to command the plurality of first distributed energy resources for balancing;
A distributed energy resource management system comprising:
The virtual substation aggregator,
a communication unit that receives the first control command information from the distributed energy resource management device;
a required controllability estimating unit that estimates controllability, which is the amount of electric power required for supply and demand control, based on the supply and demand forecast in the distribution system during the control target period;
distributing the controllability to each of the plurality of first distributed energy resources so as to minimize operating costs within the active power control range of the first control command information; a control command value determination unit that determines a first control command value including an active power control amount that is the distributed control power commanded to each of the energy resources and an output timing;
with
The distributed energy resource management system, wherein the communication unit transmits the first control command value to each of the plurality of first distributed energy resources. the distributed energy resources further include a plurality of second distributed energy resources connected to the distribution system and having voltage regulation capabilities;
The optimum power flow calculation unit of the distributed energy resource management device satisfies the constraint of the distribution system from the first voltage-current distribution and the second voltage-current distribution in addition to the active power control range, and the calculating a reactive power control amount that is the minimum value of the reactive power amount that can be output within the controllable second power amount range of the plurality of second distributed energy resources in the control target period;
The control command value calculation unit of the distributed energy resource management device includes a set value used for voltage control by reactive power in the plurality of second distributed energy resources, the reactive power control amount, and the plurality of second distributed energy resources. 12. The distributed energy resource management system according to claim 11, further generating second control command information associated with each of the energy resources. The communication unit of the distributed energy resource management device transmits the second control command information to the virtual substation aggregator,
The communication unit of the virtual substation aggregator distributes the first electric energy collected from the plurality of first distributed energy resources and the second electric energy collected from the plurality of second distributed energy resources to the distributed a second control command value that is transmitted to the energy resource management device and commands the set value and the reactive power control amount included in the second control command information to each of the plurality of second distributed energy resources; 13. The distributed energy resource management system according to claim 10 or 12, transmitting to each of the second distributed energy resources. further comprising a distribution automation system that manages the voltage and current of the second distributed energy resource;
The distribution automation system comprises a communication unit configured to transmit the second power amount collected from the plurality of second distributed energy resources to the distributed energy resource management device,
The communication unit of the virtual substation aggregator transmits the first power amount collected from the plurality of first distributed energy resources to the distributed energy resource management device,
The communication unit of the distributed energy resource management device transmits the second control command information to the distribution automation system,
The communication unit of the distribution automation system transmits a second control command value for commanding the set value and the reactive power control amount included in the second control command information to each of the plurality of second distributed energy resources. 13. The distributed energy resource management system according to claim 10 or 12, transmitting to each of a plurality of second distributed energy resources. further comprising a distribution automation system that manages the voltage and current of the second distributed energy resource;
The distribution automation system comprises a communication unit configured to transmit the second power amount collected from the plurality of second distributed energy resources to the distributed energy resource management device,
13. The apparatus according to claim 10, wherein the communication unit of the virtual substation aggregator transmits the first power amount collected from the plurality of first distributed energy resources to the distributed energy resource management device. A distributed energy resource management system as described. The communication unit of the distributed energy resource management device transmits the second control command information to the distribution automation system,
The communication unit of the distribution automation system transmits a second control command value for commanding the set value and the reactive power control amount included in the second control command information to each of the plurality of second distributed energy resources. 16. The distributed energy resource management system of claim 15, transmitting to each of a plurality of second distributed energy resources. The communication unit of the distributed energy resource management device provides a second control command for commanding the set value and the reactive power control amount included in the second control command information to each of the plurality of second distributed energy resources. 16. The distributed energy resource management system of claim 15, wherein a value is sent to each of said plurality of second distributed energy resources. Predicting the voltage and current distribution in the control target period using the actual value of the load demand in the distribution system and the actual value of the amount of power generated by the distributed energy resources capable of generating power, and transmitting the distribution to the distributed energy resource management device. 10. The distributed energy resource management system of claim 9, further comprising a forecasting system that Predicting the first voltage and current distribution and the second voltage and current distribution in the control target period using the actual value of load demand in the distribution system and the actual value of the amount of power generation in the distributed energy resource that can generate power, 12. The distributed energy resource management system of claim 11, further comprising a prediction system transmitting to the distributed energy resource manager. A distributed energy resource management program for calculating an output in a distributed energy resource including a plurality of first distributed energy resources connected to a distribution system and controlled in output active power,
to the computer,
Constraints on the voltage and current of the distribution system are observed from the voltage and current distribution of the distribution system based on the supply and demand forecast, and the first distributed energy resource is output within a controllable first power amount range during the control target period. calculating the maximum possible charge amount and discharge amount, and calculating an active power control range defined by the maximum charge amount and discharge amount;
generating first control command information that associates each of the plurality of first distributed energy resources with the active power control range;
sending the first control command information to a virtual substation aggregator that determines the amount of active power to command the plurality of first distributed energy resources;
and
A distributed energy resource management program, wherein the active power control range is a control range of the active power output from the first distributed energy resource. A distributed energy resource management program for calculating an output in a distributed energy resource including a plurality of first distributed energy resources connected to a distribution system and controlled in output active power,
to the computer,
From a first voltage and current distribution of the distribution system based on a supply and demand prediction in which the voltage and current constraints of the distribution system are observed in the control target period, and the distributed energy resource capable of generating power in the control target period has the maximum output. a maximum discharge amount that can be output within a controllable first power amount range of the first distributed energy resource during the control target period; From the second voltage and current distribution of the distribution system based on the supply and demand forecast, the maximum value of the charge amount that can be output within the range of the first electric amount in the control target period is calculated, and the discharge amount and the determining an active power control range defined by the maximum amount of charge;
generating first control command information that associates each of the plurality of first distributed energy resources with the active power control range;
sending the first control command information to a virtual substation aggregator that determines the amount of active power to command the plurality of first distributed energy resources;
and
A distributed energy resource management program, wherein the active power control range is a control range of the active power output from the first distributed energy resource.

Images